CN106907137A - A kind of method of the effective water conservancy diversion in shale oil reservoir volume fracturing crack - Google Patents
A kind of method of the effective water conservancy diversion in shale oil reservoir volume fracturing crack Download PDFInfo
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- 238000000034 method Methods 0.000 title claims abstract description 35
- 239000003079 shale oil Substances 0.000 title claims description 27
- 239000012530 fluid Substances 0.000 claims abstract description 55
- 239000002253 acid Substances 0.000 claims abstract description 44
- 239000000243 solution Substances 0.000 claims abstract description 39
- 238000002347 injection Methods 0.000 claims abstract description 37
- 239000007924 injection Substances 0.000 claims abstract description 37
- 238000007789 sealing Methods 0.000 claims abstract 2
- 239000004576 sand Substances 0.000 claims description 41
- 239000003795 chemical substances by application Substances 0.000 claims description 23
- VEXZGXHMUGYJMC-UHFFFAOYSA-N Hydrochloric acid Chemical compound Cl VEXZGXHMUGYJMC-UHFFFAOYSA-N 0.000 claims description 18
- 239000007788 liquid Substances 0.000 claims description 15
- 239000011229 interlayer Substances 0.000 claims description 6
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Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
- E21B43/267—Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/28—Dissolving minerals other than hydrocarbons, e.g. by an alkaline or acid leaching agent
- E21B43/283—Dissolving minerals other than hydrocarbons, e.g. by an alkaline or acid leaching agent in association with a fracturing process
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- Fluid Mechanics (AREA)
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Abstract
The present invention relates to oil-gas reservoir hydraulic fracturing storey increase design technical field, the method for relating more specifically to the effective water conservancy diversion in crack a kind of oil reservoir reservoir fracturing suitable for shale.It comprises the following steps：Step A：Reservoir is pre-processed using acid solution；Step B：Major fracture is made using low-viscosity fracturing fluid；Step C：Injection low-viscosity slippery water opens microcrack and branch fractures；Step D：Low-viscosity acid solution and low-viscosity slippery water are alternately injected to carry out slug；Step E：The low-viscosity slippery water and low-viscosity fracturing fluid that carry proppant respectively are implanted sequentially to support the microcrack system and the branch fractures system, wherein first proppant is differed with the second proppant；Step F：Injection carries the middle viscosity fracturing fluid of proppant to support the major fracture system respectively；Step G：The 4th proppant in pit shaft is replaced at the sealing of crack completely using the low-viscosity slippery water.
Description
Technical field
The present invention relates to oil-gas reservoir hydraulic fracturing storey increase design technical field, relate more specifically to a kind of suitable for shale oil reservoir
The method of the effective water conservancy diversion in crack in reservoir fracturing.
Background technology
China's shale oil has very large resource potentiality, and according to statistics, Chinese Main Basins can adopt shale oil stock number and be about
30×108-60×108T, is mainly distributed on Bohai Sea Gulf, loose the Liao Dynasty, Erdos, Jiang-Han Area, Zhunger Basin, south and the basin such as assists, and
Shale commercial oil is obtained in the geologic elements such as Biyang Sag, Liaohe Depression, Jiyang depression, Dong- pu Depression, is disclosed
The resource potential of China's continental basins mud shale series of strata shale oil, with the continuous decline of conventional gas and oil yield in world wide,
Shale oil exploitation has turned into the forward position of oil exploration and the hot fields of oil field increasing the storage.
Shale oil reservoir tool the content of organic matter it is high, mineral composition is complicated, laminated texture development, reservoir space it is tiny, many microns
The basic characteristics such as-nanoscale pore throat, low hole Oil in Super-low Permeability.Effective pressure break of shale oil reservoir is international problem, at present both at home and abroad
Shale oil stimulation technology ground zero, even if in north America region also in progressively exploration application, and my China more uses for reference
The correlation technique thinking of external shale gas volume fracturing transformation.
Fracture technology as unconventional shale reservoir effective exploitation one of core technology, be shale oil reservoir reservoir stimulation
One of most important means.
The A of patent CN 103306660 disclose a kind of method of shale gas reservoir hydraulic fracturing volume increase, technical characteristics：Will
Slippery water or drop block water and injected under the conditions of higher than rammell rupture stress, crack initiation stratum；Suppressed in many slug injections-temporarily stifled-seam
Pressure-induction steering-later stage proppant individual layer lays；The extremely-low density branch of chopped fiber is mixed with than the injection of, infusion discharge capacity high with low sand
Support agent；The row of returning again after vexed well.The patented method is directed to shale gas reservoir, is blocked water with different construction infusions using slippery water or drop
Program is pressurizeed to target zone, at the same be aided with temporarily stifled, seam build the pressure, super-low-density proppant single zone compaction technology, promote in layer
The superposition of multiple spot induced stress is produced, to form the artificial chicken-wire cracking of large area shearing slip, enlargement gas drainage area,
Improve well yield.
Shale gas reservoir fracturing crack with shear seam based on, support seam supplemented by.Different from shale gas, shale oil reservoir is special due to it
Different geology and seepage flow characteristics, fracturing reform have certain difference compared with shale gas, and its reservoir fracturing crack is to support seam
Main, supplemented by shearing seam, the requirement to flow conductivity is higher, and its fracturing reform core is to improve crack " effective variant
Product ", and " effective " in " effectively transforming volume " highlights increasing substantially for fracture condudtiviy.Shale oil reservoir
After pressure break requirement volume fracturing transformation, branch crack that is major fracture and being connected with major fracture, the flow conductivity of microcrack are also same
Sample need improve, fracturing technology need satisfaction ensure the main force seam it is long while, to sand than design requirement it is higher, carry as far as possible
High sand ratio, increases fracture condudtiviy.Therefore, shale oil pressure break fracturing technology thinking, liquid selective, proppant selection,
Construction injection parameter preferably etc. aspect, have certain otherness with shale gas.
Shale oil reservoir pressure break is also faced with poor validity after pressing, " effective " support hardly possible, long-term flow conductivity and keeps poor, pressure
The difficult point such as stable production period is short afterwards, both at home and abroad majority shale oil reservoirs effectively opening for such reservoir have impact on due to technical bottleneck problem
Hair and the effective of reserves employ.
The content of the invention
To solve the problems that shale oil reservoir fracture planes are faced, the effective transformation to such reservoir is realized, the present invention proposes a kind of
The method of the effective flow conductivity in shale oil volume fracturing crack is improved, so as to improve " effectively transforming volume " and the support in crack
" supporting efficiency " of agent, and the validity and fracturing transformation effect of shale oil reservoir pressure break are improved, while it is effective to reduce reservoir
Lower Limit of Producing of Ultra-low, improves reservoir use rate to greatest extent.
The invention provides a kind of method of the effective water conservancy diversion in shale oil reservoir volume fracturing crack, it comprises the following steps：
Step A：Reservoir is pre-processed using acid solution；
Step B：Major fracture is made using low-viscosity fracturing fluid, major fracture system is obtained, wherein, the low-viscosity fracturing fluid
Viscosity is 30mPas-50mPas；
Step C：Injection low-viscosity slippery water is opened and extends microcrack and branch fractures, and carries out expansion seam, obtains microcrack
System and branch fractures system, wherein, the viscosity of the low-viscosity slippery water is 1mPas-10mPas, preferably described low glutinous
The viscosity for spending slippery water is 1mPas-3mPas；
Step D：Alternating injects the low-viscosity acid solution and the N number of circulation of low-viscosity slippery water slug, further molten seam and expansion
Seam, wherein N is positive integer, and preferably N is the positive integer of 1-5；That is, to be implanted sequentially low-viscosity acid solution and described low
Viscosity slippery water is a circulation, for example, when N is 1, being initially injected low-viscosity acid solution, then the low-viscosity slippery water；
When N is 2, low-viscosity acid solution is initially injected, then the low-viscosity slippery water；Posterior circle before the step of, that is, inject
Low-viscosity acid solution, is then injected into the low-viscosity slippery water；
Step E：It is implanted sequentially described low the sticking of the second proppant of the low-viscosity slippery water and carrying for carrying the first proppant
Fracturing fluid is spent to support the microcrack system and the branch fractures system, wherein first proppant and the second proppant
Differ；
Step F：" effectively support " of major fracture to fracturing fluid, proppant type, plus sand concentration, sand feeding amount requirement all compared with
Height, therefore in order to further improve the flow conductivity of major fracture and the correctional effect in remote well area, point M stage is successively
The middle viscosity fracturing fluid for carrying the 3rd proppant and the 4th proppant is injected separately into support the major fracture system, wherein, institute
The viscosity of middle viscosity fracturing fluid is stated for 100mPas-130mPas, for example, the viscosity of the middle viscosity fracturing fluid is preferably
It is 110mPas-120mPas；3rd proppant, the 4th proppant, first proppant and the second support
Agent is different；M is positive integer, and preferably M is the positive integer of 4-10；
Step G：The 4th proppant in pit shaft is replaced at the sealing of crack completely using the low-viscosity slippery water,
The consumption of the low-viscosity slippery water is hole volume and surface line volume sum.
Wherein, in the step A, the consumption of the acid solution of pretreatment is general according to fracture simulation and construction experience, general acid
Liquid consumption 10.0-15.0m3.And acid formula will take into full account the mineral constituent of reservoir, the acid-sensitive reservoir of salt to be optimized
Acid formula, prevents acid-sensitive.
Therefore, in a specific embodiment, in the step A, the condition according to the reservoir selects the acid solution
Species and injection parameter；It is preferred that the condition of the reservoir includes the mineral constituent of the reservoir；It is preferred that the acid solution includes hydrochloric acid
And/or mud acid；It is preferred that the injection parameter includes the discharge capacity and consumption of the acid solution, the discharge capacity of more preferably described acid solution is 0.5
m3/min-1.0m3/ min, the consumption of acid solution is 10.0m3-15.0m3。
Pre-processed by acid solution, can reduce the fracture pressure and integral construction pressure of reservoir fracturing, it is to avoid initial pressure break is applied
Work pressure is high and seam longitudinal direction high that cause excessively extends even out-of-control phenomenon, is to improve crack in the stage for adding proppant the later stage
(supporting efficiency in the crack refers to the support dosage that is played a supportive role in the range of reservoir and enter the total proppant of well to supporting efficiency
The percentage of the ratio of amount) lay a solid foundation.
In a specific embodiment, in the step B, the low-viscosity fracturing fluid is used and upper and lower interlayer energy compatibility
Liquid system.Such as described low-viscosity fracturing fluid is the liquid system of anti-water-sensitive better performances.
In the step B, major fracture is made using low glutinous fracturing fluid, there are four aspect advantages：First, liquid viscosity is relatively
It is low, it is controlled beneficial to making the seam height during seam, seam excessively Longitudinal extending high is prevented, therefore, fracture height control is good；Its
Two, if fracture height control preferably, will extend in the main body of crack in reservoir, without breaking through upper and lower mudstone barriers or in interlayer
Excessive Longitudinal extending, is conducive to suppressing the expansion Injury death of interlayer mud stone, and mud cake etc. is returned after preventing interlayer hydration of mud stone from expanding
Stream influence target zone flow conductivity；Third, using the liquid of same scale, low-viscosity fracturing fluid is compared with middle high viscosity fracturing fluid
The crack seam length produced is longer；Fourth, the later stage adds proppant stage to be conducive to body supports agent to add reservoir, improve
The supporting efficiency in crack.
In a specific embodiment, in the step B, the discharge capacity of the low-viscosity fracturing fluid for using is staged liter
Discharge capacity high, preferably described discharge capacity is based on layering profile of geostress and explains and results of fracture simulation software analog result, by simulation not
Extension situation high is stitched with the crack under discharge capacity, with discharge capacity described in this determination；It is preferred that the elevated discharge capacity of staged is initial
Discharge capacity is 3m3/min-4m3/ min, the staged that the particularly preferred discharge capacity carries out 2-3 times is raised, and the staged is raised
Discharge capacity successively with 2m3/min-2.5m3The amount of/min is incremented by.For example by the elevated discharge capacity of the staged set gradually for
4.0m3/min、6.0m3/ min and 8.0m3/min.Because if discharge capacity is excessive, can directly cause the quick product of pressure in crack
Gather and rise and press off upper and lower interlayer, be unfavorable for that control seam is high and construct；Additionally, controlling to be split in work progress by displacement variation
Stitch the net pressure for extending, it is to avoid intrinsic fracture opens too early, prevent near wellbore zone from forming complex fracture.When rising to the first mesh
During mark discharge capacity, low-viscosity fracturing fluid injection is carried out with first object discharge capacity.
In a specific embodiment, in the step C, the discharge capacity of the low-viscosity slippery water for using is staged liter
Discharge capacity high；The initial displacement of the elevated discharge capacity of staged is 7m3/min-8m3/min；The particularly preferred discharge capacity is entered
The staged that row is 2-3 times is raised, and the elevated discharge capacity of staged is successively with 2m3/min-2.5m3The amount of/min is incremented by.When upper
When rising to target discharge capacity, low-viscosity slippery water injection is carried out with target discharge capacity.
In a specific embodiment, in the step C, the discharge capacity of the low-viscosity slippery water is raised by staged
Mode injects the low-viscosity slippery water, preferably described low-viscosity slippery water carry the sand of 3%-8% (percent by volume) than
First proppant injects in the way of slug formula adds the first proppant；Particularly preferred first proppant is 70/140
Purpose proppant, most preferably the first proppant is the powder pottery proppant of 70/140 mesh.Improved by gradually stepping up discharge capacity and split
The net pressure for extending is stitched, some planes of weakness (intrinsic fracture or cementing plane of weakness) open institute more than reservoir when fracture extension net pressure
During the critical pressure for needing, the Fracture System and checking of the seam narrower branch fractures wide formed after intrinsic fracture opens gradually are opened
The seam narrower microcrack system wide that seam is formed after opening.Additionally, slippery water is low due to viscosity, microcrack and branch fractures are opened
Qi Hou, it is easier to enter the branch seam system having turned on and the microcrack system connected with branch seam, with the continuous follow-up of slippery water
Injection, further realizes linking up, extending the purpose of natural microcrack and branch fractures system.
In a specific embodiment, in the step D, the viscosity of the low-viscosity acid solution and the low-viscosity slippery water
Viscosity difference be no more than 10%, the viscosity difference of the viscosity of preferably described low-viscosity acid solution and the low-viscosity slippery water does not surpass
5% is crossed, the viscosity of most preferably described low-viscosity acid solution and the viscosity of the low-viscosity slippery water are equal.
The suitable low-viscosity acid solution of viscosity and the low-viscosity slippery water are injected by N number of cycle alternation, it is possible to use low
Viscosity acid solution is artificial to link up and the further potential intrinsic fracture in unlatching flank direction to the acid corrosion action of shale reservoir,
The low-viscosity slippery water of follow-up follow-up injection can continue to expand the microcrack for extending acid etching, the branch in flank direction is stitched system
More develop, improve crack complexity.
The branch seam and microcrack system formed by way of N number of cycle alternation injects are more, are released along the stress in major fracture direction
Put effect it is more obvious, effectively prevent crustal stress act on single major fracture and to the quick reduction effect of flow conductivity, can
Major fracture flow conductivity is set to maintain the longer time.
In a specific embodiment, in the step D, in the friendship of the low-viscosity acid solution and the low-viscosity slippery water
With 1m in being circulated for each injected3/min-1.5m3The discharge capacity of/min clamp-ons a low-viscosity acid for hole volume
Liquid, and after the low-viscosity acid solution is clamp-oned and finished, in the alternately first circulation of injection, with 4m3/min-6m3/min
Discharge capacity inject the low-viscosity slippery water, then in the circulation of the alternating injection after, successively with 2m3/min-2.5
m3/ min incremental discharge capacity injects the low-viscosity slippery water.Such as, under the circulation that N is 3, low-viscosity acid solution injection discharge capacity
It is 1m3/min-1.5m3/ min, and low-viscosity slippery water injection discharge capacity is gradually stepped up under each circulation, for example can be according to
It is secondary to be：6m3/min、8m3/min、10m3/min；By this change discharge capacity injection way, low-viscosity acid solution is pushed to successively
Near wellbore zone, in remote well area, allow low-viscosity acid solution as much as possible uniform acid etching acid solution by part crack, it is effectively anti-
The only excessive consumption of acid solution takes into account and advances acid solution to crack distal end as quickly as possible again in the fracture surface of near wellbore zone, keeps away
Exempt from acid solution near wellbore zone and rock overreaction destruction rock texture, effect of caving in is caused, so as to cause fracture condudtiviy
Extreme loss.
In a specific embodiment, in the step E, the low-viscosity slippery water carries 8%-10% (percent by volume)
Sand than first proppant, first proppant preferably is selected from the proppant of 70/140 mesh, and first proppant is excellent
Select the ceramsite propping agent of 70/140 mesh；The low-viscosity fracturing fluid carry the sand of 4%-10% (percent by volume) than described the
Two proppants, preferably low-viscosity fracturing fluid carry second proppant of 5%-8% (percent by volume)；Described second
Support agent preferably includes the proppant of 40/70 mesh；Second proppant preferably includes ceramsite propping agent and/or coated sand proppant；
Such as described second proppant includes the ceramsite propping agent of 40/70 mesh or the coated sand proppant of 40/70 mesh.
In a specific embodiment, in the step E, the discharge capacity of the low-viscosity slippery water is 10m3/min-12
m3/min；The discharge capacity of the low-viscosity fracturing fluid is 10m3/min-12m3/min。
In a specific embodiment, in the step F, the discharge capacity of the middle viscosity fracturing fluid is 10m3/min-12
m3/min。
Wherein, the purpose that injection carries the low-viscosity slippery water of the first proppant is further fully to support matched fine fisssure
Seam system and branch fractures system.The purpose that injection carries the low-viscosity fracturing fluid of the second proppant is fully to support matched
Branch fractures system.
Open, extension microcrack and branch fractures on the basis of, by low-viscosity slippery water and low glutinous fracturing fluid carry respectively compared with
The proppant injection of small particle, microcrack, the branch fractures system of different scale are most stitched adaptable difference wide with it at last
The proppant pack of particle diameter, not only realizes and expands the scope of " network fracture " system, improves " transformation volume ",
And microcrack system and branch fractures system with major fracture UNICOM are fully supported, improve microcrack system, branch and split
The flow conductivity of seam system, so as to ensure after pressure that microcrack system and branch fractures system are unlikely to closure too early and oozing for losing
Stream ability.
In the step F, middle viscosity fracturing fluid relative to low slime body, because its viscosity is of a relatively high, it is difficult to enter previous
" network fracture " system of established seam relative narrower wide, especially branch crack and the microcrack system connected with branch crack,
Now crack to be mainly continue along biggest principal stress direction and extends to remote well direction, can and realize effective extension to major fracture
And the extension extension of remote well end check seam.
" the effectively support " of major fracture and main plus sand stage, especially add the high sand ratio stage in sand later stage, sand is taken to fracturing fluid
Capability Requirement is higher.Middle viscosity fracturing fluid is stronger compared with low glutinous fracturing fluid prop-carrying capacity, is more beneficial for taking sand.
In a specific embodiment, in the step F, in the 1st stage to M-2 or M-3 stage, it is described in
Viscosity fracturing fluid carry 10-30% sand than the 3rd proppant, the pottery of more preferably described 3rd proppant including 30/50 mesh
The coated sand proppant of grain proppant or 30/50 mesh, in M-1 or M-2 stage to the m-th stage, the middle viscosity pressure
Split liquid carry 25-35% sand than the 4th proppant, the haydite of more preferably described 4th proppant including 20/40 mesh supports
Agent or the coated sand proppant of 20/40 mesh.
In a specific embodiment, in the step F, the middle viscosity fracturing fluid can include guanidine gum fracturing fluid and gather
The liquid such as compound fracturing fluid.
In a specific embodiment, in the step G, the injection rate of the low-viscosity fracturing fluid is 12m3/min
-14m3/min。
Because the parameter being related in the present invention is numerous, and the characteristic in specific oil field is extremely complex, accordingly, it would be desirable to according to existing
Situation rationally determines the parameter in method in the present invention, but the step of its implementation and principle do not depart from design of the invention and
Scope.
In the present invention, described " viscosity " is " apparent viscosity ".
The terms such as major fracture of the invention, branch fractures and microcrack belong to well known to a person skilled in the art scope.
Beneficial effects of the present invention：
The present invention by the optimization to pressing crack construction technique and the optimization of fracturing liquid system and reasonable coordination application, to master
In crack, branch fractures, the abundant communication of microcrack and spread foundation, by major fracture and the branch connected with major fracture
Crack, " the effectively support " of microcrack, improve fracturing reform volume and crack complexity degree, improve shale oil reservoir
The whole Fracture System " effective flow conductivity " of reservoir fracturing, can effectively solve to be faced in unconventional shale oil reservoir reservoir fracturing
Transformation finite volume, " effective " support of Fracture System is difficult, long-term flow conductivity keeps validity difference and pressure after poor, pressure
The difficult point such as stable production period is short afterwards, so as to realize the effective transformation to such reservoir, improves correctional effect and stable production period after pressure.
Method involved in the present invention and technique thinking are succinct, and scene is easy to operation to implement, compared with current shale fracturing technology and side
Method, without increasing extra corollary apparatus, whole construction technology cost is less than or close to current prevailing technology, cost efficiency effect
Substantially.Of the present invention and method and technique thinking successful Application at home shale oil hide trial zone fracturing reform scheme it is excellent
Change in design and field test, field test application effect is good, is suitable for the High Efficiency Reform of shale oil reservoir.
Brief description of the drawings
Fig. 1 is shown A well pressure break infusion programme diagrams.The unit of the proppant concentration (ordinate) in the figure is Kg/m3,
Its meaning is the quality of the proppant contained by the liquid of unit volume.It is the body of proppant without unit and sand ratio is volume ratio
Product is divided by volume (such as body of the volume of low-viscosity fracturing fluid or middle viscosity fracturing fluid for carrying the neat liquid before proppant
Product).Sand is than the corresponding reduction formula with sand concentration：Sand concentration (Kg/m3Bulk density (the g/cm of)=sand ratio × proppant3)
×1000。
Fig. 2 is shown the A well pressure break clusters crack profile in whole process of constructing.
Fig. 3 is shown in whole process of constructing acid solution profile figure in the fracturing fracture of A well pressure break clusters.
Specific embodiment
With reference to embodiment, the invention will be further described, but protection scope of the present invention is not limited to following implementations
Example.
Drag reducer, clay stabilizer, cleanup additive, thickener, crosslinking agent, expansion-resisting agent and the demulsifier used in the present invention are equal
Purchased from petroleum works Institute for Research and Technology of Sinopec Group；Proppant, such as ceramsite propping agent are purchased from commercially available
Product.
Acid solution, low-viscosity acid solution, low-viscosity fracturing fluid, medium-high viscosity fracturing fluid and low-viscosity slippery water in the present invention it is glutinous
Degree is measured using commercially available rotary viscosimeter or rheometer.
Embodiment 1
A wells are a bite shale oil pilot test horizontal well of certain oil field block, the well construction interval of interest
The horizontal segment length 400m of 1516.0-1916.0.0m, A；Interval of interest lithology is white clouds matter shale, intrinsic fracture comparative development；
Target zone temperature is 68 DEG C, Young's modulus 24-27Gpa, Poisson's ratio 0.23-0.25, minimum horizontal principal stress 26-29Mpa,
Maximum horizontal principal stress 32-35Mpa, overlying formation pressure 34-37MPa, horizontal stress coefficient of variation：0.03-0.15 is crisp
Sex index 73%.
The method of the raising effective flow conductivity in shale oil volume fracturing crack proposed using this patent, to 5 sections of well point, often
4 shower holes of section, single cluster 0.75m, cluster spacing 15-20m, have carried out the design of fracturing reform scheme optimization and the scene of the well
Pilot test, fracturing string uses light casing fracturing mode, and specific implementation method is：
(1) slippery water formula：+ 0.1% cleanup additive of clay stabilizer of 0.10% drag reducer+0.3%+clear water, viscosity exists
1.1mPas-2.0mPas, density 0.99-1.02g/cm3(25 DEG C), pH value 6.5-7.5, drag reducing efficiency 65%-70%；Herein
Using etc. viscosity slippery water and hydrochloric acid, by adjusting slippery water formula, slippery water viscosity is adjusted to 1.28mPas or so,
It is consistent with 15% hydrochloric acid viscosity (25 DEG C, 1.28mPas).
(2) low-viscosity pressure break formula of liquid：The cleanup additive of+0.3% expansion-resisting agent of 0.3% thickener+0.1%, pH value 6-7, liquid is sticked
Degree 30mPs-50mPs or so.
(3) viscosity pressure break formula of liquid in：The cleanup additive+0.1% of+0.3% expansion-resisting agent of+0.2% crosslinking agent of 0.5% thickener+0.1% breaks
Emulsion, base fluid density 1.10g/cm3Left and right, pH value 6-7, viscosity 100mPs-130mPs or so.
(4) with 1.0m3The discharge capacity of/min in pit shaft to clamp-oning 15m3Concentration is 15% hydrochloric acid.
(5) it is quick to start fracturing unit truck group, with 4m3/ min discharge capacity starting, with 2m3/ min increases by two ladders and raises row
Amount (that is, is divided into three phases：First stage 4.0m3/ min, second stage 6.0m3/ min and three phases
8.0m3/ min) mode constructed, and uses 4.0m3/ min discharge capacities inject 40m3Low-viscosity fracturing fluid, uses 6.0m3/ min is arranged
Amount injection 70m3Low-viscosity fracturing fluid, uses 8.0m3/ min discharge capacities inject 90m3Low-viscosity fracturing fluid, injects 200m altogether3
Low-viscosity fracturing fluid.
(6) quick ladder lifting discharge capacity (that is, is divided into three phases：First stage 8.0m3/ min, second stage
10.0m3/ min and three phases 12.0m3/ min), 8.0m3/ min discharge capacities continue 1-2 minutes, 10.0m3/ min discharge capacities
Continue 1-2 minutes；When rising to 12.0m3During/min, with 12.0m3/ min discharge capacities carry out the injection construction of low-viscosity slippery water,
Low-viscosity slippery water 185m is injected altogether3；And during low-viscosity slippery water is injected, add sand mode to carry with slug formula
The sand of 3%-8% than 70/140 mesh powder make pottery proppant.
(7) 3 grades of slugs (3 slugs of circulation) of low-viscosity slippery water and 15% hydrochloric acid are alternately injected：1st grade of slug：
Injection 21m3Hydrochloric acid, is then injected into 40m3Low-viscosity slippery water；2nd grade of slug：Injection 21m3Hydrochloric acid, then 70m3
Low-viscosity slippery water；3rd level slug：Injection 21m3Hydrochloric acid, then 100m3Low-viscosity slippery water.3 grades are alternately injected
During, the injection discharge capacity of hydrochloric acid is 1m3/ min, injected slurry volume is a wellbore volume (21m3), the 1st grade of slug
Middle low-viscosity slippery water discharge capacity is 6m3/ min, low-viscosity slippery water discharge capacity is 8m in the 2nd grade of slug3/ min, the first level segment
Low-viscosity slippery water discharge capacity is 12m in plug3/min。
(8) with 12m3The discharge capacity injection 60m of/min3Low-viscosity slippery water, and in injection process carry one 10%
The powder pottery proppant of 70/140 mesh of sand ratio (percent by volume)；Then with 12m3The discharge capacity injection 120m of/min3In stick
Degree fracturing fluid, and carry 40/70 mesh of 4%, 6% and 8% sand ratio (percent by volume) in injection process low-viscosity fracturing fluid
Ceramsite propping agent, the ceramsite propping agent of 40/70 mesh adds sand or continuity plus sand mode to add with slug formula.
(9) with 12m3The discharge capacity injection 200m of/min3Middle viscosity fracturing fluid, viscosity is being noted in 120mPs or so
The ceramsite propping agent that fracturing fluid carries 30/50 mesh of 10%-30% sand ratio (percent by volume), 30/50 mesh are sticked during entering
Ceramsite propping agent add sand mode to add with continuity；With 14m3The discharge capacity injection 50m of/min3Middle viscosity fracturing fluid, and
Viscosity fracturing fluid carries the ceramsite propping agent of 20/40 mesh of 25%-40% sand ratio (percent by volume), 20/40 in injection process
Purpose ceramsite propping agent adds sand mode to add with continuity.
(10) with 14m3The discharge capacity injection 22m of/min3Low-viscosity slippery water, then termination of pumping pressure measurement drop, terminates after pressure measurement drop
Pressing crack construction.
Pressure break pilot test is carried out to the test well and certain some mouthfuls of well of experiment by above-mentioned steps, site construction technology is obtained
Success, obtains good volume increase stable yields effect after pressure, production decline speed substantially slows down after pressure, achieves significant increasing oil
Effect, improves the fracturing transformation effect of such reservoir.
Claims (12)
1. the method for the effective water conservancy diversion in a kind of shale oil reservoir volume fracturing crack, it comprises the following steps：
Step A：Reservoir is pre-processed using acid solution；
Step B：Major fracture is made using low-viscosity fracturing fluid, major fracture system is obtained, wherein, the low-viscosity fracturing fluid
Viscosity is 30mPas-50mPas；
Step C：Injection low-viscosity slippery water is opened and extends microcrack and branch fractures Fracture System, wherein, it is described low glutinous
The viscosity for spending slippery water is 1mPas-10mPas, and the viscosity of preferably described low-viscosity slippery water is 1mPas-3mPas；
Step D：Alternating injects the low-viscosity acid solution and the N number of circulation of low-viscosity slippery water slug, further molten seam and expansion
Seam, wherein N is positive integer, and preferably N is the positive integer of 1-5；
Step E：It is implanted sequentially described low the sticking of the second proppant of the low-viscosity slippery water and carrying for carrying the first proppant
Fracturing fluid is spent to support the microcrack system and the branch fractures system, wherein first proppant and the second proppant
Differ；
Step F：M stage is divided to be injected separately into the middle viscosity fracturing fluid for carrying the 3rd proppant and the 4th proppant successively to support
The major fracture system, wherein, the viscosity of the middle viscosity fracturing fluid is 100mPas-130mPas, the 3rd support
Agent, the 4th proppant, first proppant and the second proppant are different；M is positive integer, and preferably M is 4-15
Positive integer；
Step G：The 4th proppant in pit shaft is replaced at the sealing of crack completely using the low-viscosity slippery water,
The consumption of the low-viscosity slippery water is hole volume and surface line volume sum.
2. method according to claim 1, it is characterised in that in the step A, the condition choosing according to the reservoir
Select the species and injection parameter of the acid solution；It is preferred that the condition of the reservoir includes the mineral constituent of the reservoir；It is preferred that described
Acid solution includes hydrochloric acid and/or mud acid；It is preferred that the injection parameter includes the discharge capacity and consumption of the acid solution, more preferably described acid solution
Discharge capacity be 0.5m3/min-1.0m3/ min, the consumption of acid solution is 10.0m3-15.0m3。
3. method according to claim 1 and 2, it is characterised in that in the step B, the low-viscosity fracturing fluid
Using the liquid system with the energy compatibility of interlayer up and down of target zone.
4. the method according to any one in claim 1-3, it is characterised in that in the step B, the institute of use
The discharge capacity for stating low-viscosity fracturing fluid is the elevated discharge capacity of staged；It is preferred that the discharge capacity is based on layering profile of geostress and explaining and splitting
Seam simulation softward analog result, stitches extension situation high, with discharge capacity described in this determination by simulating crack under different displacements；
It is preferred that the initial displacement of the elevated discharge capacity of staged is 3m3/min-4m3/min；The particularly preferred discharge capacity is carried out
The staged of 2-3 times is raised, and the elevated discharge capacity of staged is successively with 2m3/min-2.5m3The amount of/min is incremented by.
5. the method according to any one in claim 1-4, it is characterised in that in the step C, the institute of use
The discharge capacity for stating low-viscosity slippery water is the elevated discharge capacity of staged；The initial displacement of the elevated discharge capacity of staged is 7
m3/min-8m3/min；The staged that the particularly preferred discharge capacity carries out 2-3 times is raised, and the elevated discharge capacity of staged is successively
With 2m3/min-2.5m3The amount of/min is incremented by.
6. the method according to any one in claim 1-5, it is characterised in that in the step C, by ladder
The mode that formula raises the discharge capacity of the low-viscosity slippery water injects the low-viscosity slippery water, and preferably described low-viscosity slippery water is taken
Sand with 3%-8% than first proppant injected in the way of slug formula adds sand；Particularly preferred first proppant is
The ceramsite propping agent of 70/140 mesh.
7. the method according to any one in claim 1-6, it is characterised in that in the step D, it is described low glutinous
Spend acid solution viscosity and the low-viscosity slippery water viscosity difference be no more than 10%, the viscosity of preferably described low-viscosity acid solution and
The viscosity difference of the low-viscosity slippery water is no more than 5%, and the viscosity and the low-viscosity of most preferably described low-viscosity acid solution are smooth
The viscosity of water is equal.
8. the method according to any one in claim 1-7, it is characterised in that in the step D, described low
With 1m in each circulation of the alternating injection of viscosity acid solution and the low-viscosity slippery water3/min-1.5m3The discharge capacity of/min is squeezed
Enter a low-viscosity acid solution of hole volume, and after the low-viscosity acid solution is clamp-oned and finished, in the head of alternately injection
In individual circulation, with 4m3/min-6m3The discharge capacity of/min injects the low-viscosity slippery water, and then the alternating after is injected
In circulation, successively with 2m3/min-2.5m3/ min incremental discharge capacity injects the low-viscosity slippery water.
9. the method according to any one in claim 1-8, it is characterised in that in the step E, it is described low glutinous
Degree slippery water carry the sand of 8%-10% than first proppant, first proppant preferably includes the haydite of 70/140 mesh
Proppant；The low-viscosity fracturing fluid carry the sand of 4%-8% than second proppant, second proppant preferably wraps
Include the ceramsite propping agent of 40/70 mesh or the coated sand proppant of 40/70 mesh.
10. the method according to any one in claim 1-9, it is characterised in that described low in the step E
The discharge capacity of viscosity slippery water is 10m3/min-12m3/min；The discharge capacity of the low-viscosity fracturing fluid is 10m3/min-12
m3/min。
11. method according to any one in claim 1-10, it is characterised in that in the step F, it is described in
The discharge capacity of viscosity fracturing fluid is 10m3/min-12m3/min。
12. method according to any one in claim 1-11, it is characterised in that in the step F, the 1st
The individual stage to M-2 or M-3 stage, the middle viscosity fracturing fluid carry 10-30% sand than the 3rd proppant, more
The ceramsite propping agent of preferably described 3rd proppant including 30/50 mesh or the coated sand proppant of 30/50 mesh, in M-1 or
The M-2 stage to m-th stage, the middle viscosity fracturing fluid carry 25-40% sand than the 4th proppant, more preferably
Ground the 4th proppant includes the ceramsite propping agent of 20/40 mesh or the coated sand proppant of 20/40 mesh.
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